Emissions for Modeling Scenarios for EPA's Final BART Rule for Navajo Generating Station EPA, March 2014

Latest revision: sjb 2014-03-07

Note that the numbering for the control scenarios is different from that used in the 2009 ANPRM and the 2013 Proposed Rulemaking

Code Name Description

Abbreviation 

(e.g. for graphs) unit 1 unit 2 unit 3 NOx, lb/hr SO2 lb/hr

F1 SCR is BART SCR+LNB+SOFA on Units 1 - 3 (0.055 lb/MMBtu), SO2 

conversion 0.67% SCRall_055 SCR .055 SCR .055 SCR .055 1,506 1,591

F2 TWG A1-2020 Close one unit, LNB+SOFA on remaining two units cl2+LNB LNB (closed) LNB 4,309 1,064

F3 TWG A1-2031 Close one unit, SCR+LNB+SOFA on 2 units (0.07 

lb/MMBtu), SO2 conversion 0.67% cl2+SCR SCR .07 (closed) SCR .07 1,257 1,064

F4 TWG A2-2020 Close one unit, increase capacity on remaining two units 

by 189 MW total, LNB+SOFA on two units cl2+incr+LNB incr, LNB (closed) incr, LNB 4,851 1,198

F5 TWG A2-2031 Close one unit, increase capacity on remaining two units 

by 189 MW total, SCR (0.07) on two units cl2+incr+SCR SCR .07 (closed) SCR .07 1,415 1,198

F6 TWG A3-2020 Reduce capacity of Unit 2 by 561 MW total; LNB+SOFA 

on 3 units curt2+LNB LNB curt, LNB LNB 4,878 1,197

F7 TWG A3-2031a Reduce capacity on Unit 2 by 561 MW, SCR on units 1 

and 3 (0.07), LNB+SOFA on unit 2 curt2+SCR13 SCR .07 curt, LNB SCR .07 1,827 1,197

F8 TWG A3-2031b Reduce capacity equally on 3 units with SCR by 561 MW

total; SCR on Units 1 and 3 (0.07). curt123+SCR13 curt, SCR .07 curt, LNB curt, SCR .07 2,639 1,193

F9 TWG A3-2013c Reduce capacity on Units 1 and 3 by 561 MW total; SCR 

on Units 1 and 3 (0.07) curt13+SCR13 SCR .07, curt LNB SCR .07, curt 3,047 1,192

cl=close, incr=increase, curt=curtail; unit numbers

Corresponding spreadsheet tabs have titles combining Code and Name above.

The spreadsheet tab "Baseline stack data" has stack parameters.

The spreadsheet tab "CALPUFF" has modeling emissions from all scenarios in a single table.

Modeling Scenarios from 2013 Notice of Proposed Rulemaking that are still Applicable and Used for Final Rule

Code Name Description Abbreviation unit 1 unit 2 unit 3 NOx, lb/hr SO2 lb/hr

N0 Baseline 2001 - 2003 baseline Base none none none 12661 1591

N1 Control Option 1 LNB + SOFA on Units 1 - 3, 0.24 lb/MMBtu LNB LNB LNB LNB 6570 1591

N8 Control Option 8 SNCR+LNB+SOFA on Units 1 - 3, NOx at 0.18 lb/MMBtu SNCRhi SNCR .18 SNCR .18 SNCR .18 4928 1591

NOx controls on the three units Total emissions

NOx controls on the three units Total emissions
EPA revisions to values used in Proposed Rule

MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SCR, hot side ESP, 

wet FGD

211,074 8,795 0.593 5.85 487.75 0.055 89% 5.80

Navajo 2

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SCR, hot side ESP, 

wet FGD

226,163 9,423 0.593 6.32 526.92 0.056 88% 6.22

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SCR, hot side ESP, 

wet FGD

219,778 9,157 0.593 6.91 576.17 0.063 88% 6.04

Maximum Emissions Including 

Navajo Units 

Facility Unit Description

Maximum SO2 Emissions (c) Maximum Heat Input Maximum NOx Emissions (a)

Maximum 

Sulfur 

Content (b)

f1: Low NOx Burners, Separated Overfire Air, and Selective Catalytic Reduction (Units 1, 2 & 3

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs are explained separately

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01
Unit conversion for ammonia slip from ppmvd to lb/hr

NH3 0.75 ppmvd at 6% O2 Method 19 (SO2 removal efficiency) formula, Eq. 19-1:

0.00045 lb/MMBtu E = Cd*Fd*20.9/(20.9 - %O2d)

unit 1 3.99 lb/hr Cd = Pollutant concentration, dry basis

unit 2 4.27 lb/hr Fd = volumes of combustion components per unit of heat c

unit 3 4.15 lb/hr %O2d = Concentration of oxygen on a dry basis, percent.

Table 19-2 gives F factor for bituminous coal as Fd = 9780 

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures of the air preheater.

SCR conversion of SO2 to SO3

99.50% = fraction SO2 remaining after 3 layers, corresponding to 0.5% conversion

layers conversion

1 0.17%

2 0.33%

3 0.50%

4 0.67%

(5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no ammonia slip, and controls are assumed to 

affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.)

(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Eastern Bituminous coal (e.g. low alkalinity c

(strongly alkaline coal)

(4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservatively assume all in four place at start. 1 - (

(k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR.

(l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice those of H2SO4; otherwise, ammonium b

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 

EPA revisions to Values used in ANPRM (3-7-11)

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March

value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FG

EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(1) set HCl and HF to zero

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 

(h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. 

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998.

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emiss

(e) Maximum of 6 stack test results for the 2001 to 2006 period.
Penetration factors H2SO4 AbS and AS PM, general

p % ctrl p % ctrl p % ctrl

hot-side ESP 0.63 37% 0.01 99% 0.01 99%

Air Preheater 0.50 50% 0.75 25%

Wet FGD (scrubber) 0.47 53% 0.50 50%

EPRI H2SO4 doc EPRI NH3 doc
fine total fine soil EC

lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

483.71 0.055 0.026 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 51.88 (h) 16.70 (i) 16.36

518.29 0.055 0.021 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 55.59 (h) 17.89 (i) 17.53

503.66 0.055 0.031 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 54.02 (h) 17.39 (i) 17.03

 Emissions Including Speciated PM10 Emissions

Navajo Units 1, 2, and 3

Filterable PM10 Condensable PM10

Maximum Filterable

PM Emissions

aximum NOx Emissions (d)

SO4

duction (Units 1, 2 & 3) _ EPA modified to use Ultra-low activity catalyst and NOx limit 0.055 lb/MMBtu

t 2 based on 11/13/02, and Unit 3 based on 01/31/02.

H2SO4

plained separately

lue of 10,496 Btu/lb based on 01/08/03.

total coarse

Fine

total
efficiency) formula, Eq. 19-1:

Atmosphere is 20.9% oxygen

on, dry basis Ammonia M.W. is 17 lb/lb.mol

on components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

oxygen on a dry basis, percent.

or bituminous coal as Fd = 9780 sdcf/10^6 Btu

ir preheater.

slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total amount of SO4 matters for modeling. (Since all SO4 forms are assumed to be 

uminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal 

me all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see below

H2SO4; otherwise, ammonium bisulfate is formed. 

stitute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating 

e flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. 

it 2 based on 03/12/01, and Unit 3 based on 03/26/01.

t 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction

ember 1998.

missions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

lb/hr lb/hr lb/hr lb mole/hr lb mole/hr mole ratio lb mole/hr lb mole/hr lb mole/hr lb mole/hr lb/hr lb/hr

35.18 (j) 71.06 3.99 (k) 0.234 0.724 0.323 0.490 0.234 0.000 0.000 0.00 17.64

37.69 (j) 76.13 4.27 (k) 0.251 0.776 0.323 0.525 0.251 0.000 0.000 0.00 18.90

36.63 (j) 73.99 4.15 (k) 0.244 0.754 0.323 0.510 0.244 0.000 0.000 0.00 18.36

organic

Ammonia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

Net NH3 

after 

reaction & 

WFGD

[NH3] after 

reaction [NH3]

H2SO4 + 

AbS + AS 

post-control

[H2SO4] 

after 

reaction

[NH3] / 

[H2SO4] 

ratio

[H2SO4]

H2SO4 

before NH3 

interaction, 

after ESP

[AS] or 

[(NH4)2SO

4] after 

reaction

NH3 Slip

[AbS] or 

[NH4HSO4] 

after 

reaction
ms are assumed to be 

010 for PRB coal 

.593% and the heating 

.07 x 0.63 x 0.9 x 0.47. 

shutdown or malfunction.

For copying to Word version of tables

Highlight numbers portion of table here, copy; then goto Word

f1: SCR Units 1 - 3

H2SO4 HCl HF HCl + HF HCl+HF+

Pmfine

Max Heat 

Input SO2 NOx

lb/hr lb/hr lb/mmbtu lb/mmbtu lb/Mmbtu lb/hr new PM 

fine MMBtu/hr lb/MMBtu lb/MMBtu

16.35 206.02 0.0019 0 0 0 63.86 Unit 1 8,795 0.06 0.06

17.52 189.178 0.0019 0 0 0 55.27 Unit 2 9,423 0.06 0.06

17.03 245.192 0.0019 0 0 0 79.28 Unit 3 9,157 0.06 0.06

Max Heat 

Input SO2 NOx

Total PM10

Total 

Effective 

SO4 for 

modeling
MMBtu/hr lb/hr lb/hr

Unit 1 8,795 487.75 483.71

Unit 2 9,423 526.92 518.29

Unit 3 9,157 576.17 503.66

1505.66

ion of tables

 here, copy; then goto Word, highlight numbers section of its table, paste

Filterable PM10 Condensable PM10 (CPM)Filterable PM

H2SO4 NH3 PM coarse PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.0019 0 0.010 0.007 0.00028 0.0019 0.0040 0.026

0.0019 0 0.008 0.006 0.00023 0.0019 0.0040 0.021

0.0019 0 0.012 0.009 0.00033 0.0019 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) lb/hr with pollutants in order expected by CALPUFF, r

H2SO4 NH3 PM coarse PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test
lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX

16.700 86.89 63.86 2.45 16.35 35.18 228.66 f1 NGS1 487.75 16.35 483.71

16.700 75.20 55.27 2.12 17.52 37.69 197.89 f1 NGS2 526.92 17.52 518.29

16.700 107.87 79.28 3.05 17.03 36.63 283.88 f1 NGS3 576.17 17.03 503.66

ected by CALPUFF, rounded to 2 decimals
HNO3 NO3 SOA PM

F PMC EC

00 35.18 63.86 86.89 2.45

00 37.69 55.27 75.20 2.12

00 36.63 79.28 107.87 3.05
1,3; close #2

Filterable PM10 Condensable PM10 (CPM) Filterable PM

SO2 NOx H2SO4 NH3 PM coarse PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.06 0.24 0.00027 0 0.010 0.007 0.00028 0.00026 0.0040 0.026

0.00 0.00 0.00000 0 0.000 0.000 0.00000 0.00000 0.0000 0.000

0.06 0.24 0.00027 0 0.012 0.009 0.00033 0.00026 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) Filterable PM lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SO2 NOx H2SO4 NH3 PM coarse PM fine PM fine inorganic organic Max Stack 

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC

487.75 2110.74 2.37 0 86.89 63.86 2.45 2.32 35.18 228.66 f2 NGS1 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45

0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 f2 NGS2 0.00 0.00 0.00 0 0 0.00 0.00 0.00 0.00

576.17 2197.78 2.47 0 107.87 79.28 3.05 2.42 36.63 283.88 f2 NGS3 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05

09000064817e49bb f2 TWGA1-2020 7/28/2014
f3: SCR on #1,3; close #2

Filterable PM10 Condensable PM10 (CPM) Filterable PM

Max Heat 

Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 8,795 0.06 0.07 0.0019 0 0.010 0.007 0.00028 0.0019 0.0040 0.026

Unit 2 0 0.00 0.00 0.0000 0 0.000 0.000 0.00000 0.0000 0.0000 0.000

Unit 3 9,157 0.06 0.07 0.0019 0 0.012 0.009 0.00033 0.0019 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) lb/hr with pollutants in order expec

Max Heat 

Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen

Unit 1 8,795 487.75 615.63 16.70 0 86.89 63.86 2.45 16.35 35.18 228.66 f3

Unit 2 0 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00 f3

Unit 3 9,157 576.17 641.02 17.39 0 107.87 79.28 3.05 17.03 36.63 283.88 f3
b/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC

NGS1 487.75 16.35 615.63 0 0 35.18 63.86 86.89 2.45

NGS2 0.00 0.00 0.00 0 0 0.00 0.00 0.00 0.00

NGS3 576.17 17.03 641.02 0 0 36.63 79.28 107.87 3.05
EPA revisions to values used in ANPRM

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

237,669 9,903 0.593 6.59 549.21

Navajo 2 Close Unit

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

247,470 10,311 0.593 7.79 648.76

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs 

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a he

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/1

malfunction.

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/1

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/0

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions 

f4: Close one unit, increase capacity on 

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of 

(h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Res

value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 10

EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 19
EPA Revisions for Final Rule

(1) Close Unit 2 because this is the unit with the most space congestion (for SCR installation) due to coal conveyor

(2) increase capacity on remaining two units equally by 189 MW (net) total (or 94.5 MW net increase on each unit). A 94.5 MW 

(3) increase daily SO2 emissions also by 1.126

(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Ea

PRB coal (strongly alkaline coal)

EPA revisions to Values used in ANPRM (3-7-11)

(1) set HCl and HF to zero

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 
lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr

0.055 44% 28.52 2,376.69 0.240 0.0260 257.48 172.51 (f)

0.063 41% 29.70 2,474.70 0.240 0.0310 319.65 214.16 (f)

tnotes/emission inputs are explained separately

fur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

3 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year perio

3 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

3 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

m SO2 Emissions (c) Maximum NOx Emissions (d)

Maximum Emissions Including Speciated PM10 Emissions 

Navajo Units 1, 2, and 3

ncrease capacity on remaining two unit by total of 189 MW (net), LNB+SOFA on remaining tw

Maximum Filterable

PM Emissions

total

.5) based on AP-42, Table 1.1-6, September 1998.

stion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boye

er Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% durin

ater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.59

42, Table 1.1-5, September 1998. 
 to coal conveyor

ase on each unit). A 94.5 MW net increase = 844.5 net capacity = 1.126 higher than 750 MW. Therefore, increase max heat input by factor o

ugh air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 
fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

97.84 (f) 74.67 (f) 71.9 (g) 2.76 (g) 42.28 (h) 2.67 (i) 2.62 39.61 (j)

121.47 (f) 92.70 (f) 89.3 (g) 3.43 (g) 44.03 (h) 2.78 (i) 2.73 41.25 (j)

e of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

B+SOFA on remaining two units

Condensable PM10

organic

Filterable PM10

coarse

Fine

total H2SO4 SO4

bon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

 Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating 

s are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. 
 increase max heat input by factor of 1.126

2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for 
H2SO4 HCl HF HCl + HF HCl+HF+

Pmfine

HCl+HF+

Pmfine EC

lb/hr lb/mmbtu lb/mmbtu lb/Mmbtu lb/hr new PM 

fine lb/mmbtu lb/mmbtu

214.79 0.00027 0 0 0.00 71.91 0.007 0.00028

258.19 0.00027 0 0 0.00 89.27 0.009 0.00033

Total PM10

For copying to Word versio

Highlight numbers portion of table h

f4: LNB on #1,3 w/incr capy; clos

coarse SO4 organic Max Heat 

Input

lb/mmbtu lb/mmbtu lb/mmbtu MMBtu/hr

0.010 0.00026 0.0040 Unit 1 9,903

Unit 2 0

0.012 0.00026 0.0040 Unit 3 10,311

Max Heat 

MMBtu/hr

Unit 1 9,903

Unit 2 0

Unit 3 10,311

ying to Word version of tables

umbers portion of table here, copy; then in Word, highlight numbers section of its table, paste

n #1,3 w/incr capy; close #2

Filterable PM10 Condensable PM10 (CPM)Filterable PM

SO2 NOx H2SO4 NH3 PM coarse PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.06 0.24 0.00027 0 0.010 0.007 0.00028 0.00026 0.0040 0.026

0.00 0.00 0.00000 0 0.000 0.000 0.00000 0.00000 0.0000 0.000

0.06 0.24 0.00027 0 0.012 0.009 0.00033 0.00026 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM)Filterable PM

SO2 NOx H2SO4 NH3 PM coarse PM fine PM fine inorganic organic Max Stack 

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

549.21 2376.69 2.67 0 97.84 71.91 2.76 2.62 39.61 257.48

0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0.00

648.76 2474.70 2.78 0 121.47 89.27 3.43 2.73 41.25 319.65

Filterable PM

Filterable PM lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

scen SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF

f4 NGS1 549.21 2.62 2376.69 0 0 39.61 71.91

f4 NGS2 0.00 0.00 0.00 0 0 0.00 0.00

f4 NGS3 648.76 2.73 2474.70 0 0 41.25 89.27

PMC EC

97.84 2.76

0.00 0.00

121.47 3.43
EPA revisions to values used in Proposed Rule

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SCR, hot side ESP, 

wet FGD

237,669 9,903 0.593 6.59 549.21

Navajo 2 Close Unit

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SCR, hot side ESP, 

wet FGD

247,470 10,311 0.593 7.79 648.76

Unit conversion for ammonia slip from ppmvd to lb/hr

NH3 0.75 ppmvd at 6% O2

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions 

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a he

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/1

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/1

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

f5: Close one unit, increase net capacity of rem

(l) Ammonia is assumed to react with SO4 to form ammonium sulfate per EPRI 2008 if the molecules of NH3 are at least twice 

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of 

(h) Total condensable PM10 is the sum of H2SO4 and organic condensable PM10 emissions. 

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Res

value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 10

EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 19

(k) Ammonia slip is 0.75 ppmvd at 6% O2 for SCR.

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs 

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/0
0.00045 lb/MMBtu

unit 1 4.49 lb/hr

unit 2 0.00 lb/hr

unit 3 4.68 lb/hr

(6) The 0.63 ESP penetration is applied to H2SO4 before the ammonia reaction, which mainly occurs in the lower temperatures 

SCR conversion of SO2 to SO3

99.50% = fraction SO2 remaining after 3 layers, corresponding t

layers conversion

1 0.17%

2 0.33%

3 0.50%

4 0.67%

EPA Revisions for Final Rule

(1) Close Unit 2 because this is the unit with the most space congestion (for SCR installation) due to coal conveyor

(2) increase capacity on remaining two units equally by 189 MW (net) total (or 94.5 MW net increase on each unit). A 94.5 MW 

(3) increase daily SO2 emissions also by 1.126

Penetration factors H2SO4 AbS and AS PM, general

p % ctrl p % ctrl p

hot-side ESP 0.63 37% 0.01 99% 0.01

Air Preheater 0.50 50% 0.75 25%

Wet FGD (scrubber) 0.47 53% 0.50 50%

EPRI H2SO4 doc EPRI NH3 doc

(5) Ammonia slip calculation only affects split between H2SO4 and ammonium sulfate/bisulfate. Since in this case there is no am

affected the same way, the SO4 for modeling can also be calculated directly from H2SO4 * 96.06/98.08.)

EPA revisions to Values used in ANPRM (3-7-11)

(1) set HCl and HF to zero

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 

(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Ea

(strongly alkaline coal)

(4) 0.67% SO2 to SO3 conversion efficiency : Three layers give 0.5% conversion; may not have 4th till 3rd year, but conservativ
lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr

0.055 84% 8.32 693.20 0.070 0.026 257.48 172.51 (f)

0.063 83% 8.66 721.79 0.070 0.031 319.65 214.16 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1:

Maximum Emissions Including Speciated PM10 Emissions

Navajo Units 1, 2, and 3

m SO2 Emissions (c) Maximum NOx Emissions (d)

total

fur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

3 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year perio

3 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

Maximum Filterable

PM Emissions

ease net capacity of remaining two units by total of 189 MW, operate remaining two units with SCR+LNB+SO

ules of NH3 are at least twice those of H2SO4; otherwise, ammonium bisulfate is formed. 

.5) based on AP-42, Table 1.1-6, September 1998.

stion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boye

er Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% durin

ter, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.59

42, Table 1.1-5, September 1998. 

notes/emission inputs are explained separately

 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.
E = Cd*Fd*20.9/(20.9 - %O2d) Atmosphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Ammonia M.W. is 17 lb/lb.mol

Fd = volumes of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

%O2d = Concentration of oxygen on a dry basis, percent.

Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

curs in the lower temperatures of the air preheater.

after 3 layers, corresponding to 0.5% conversion

 to coal conveyor

ase on each unit). A 94.5 MW net increase = 844.5 net capacity = 1.126 higher than 750 MW. Therefore, increase max heat input by factor o

% ctrl

99%

ince in this case there is no ammonia slip, and controls are assumed to affect all these the same way, the split is irrelevant, and only total am

ugh air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 

th till 3rd year, but conservatively assume all in four place at start. 1 - (1 - 0.005)^(3/4) or 0.005*4/3 are both about 0.0067 = 0.67%, see belo
fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

97.84 (f) 74.67 (f) 71.9 (g) 2.76 (g) 58.41 (h) 18.80 (i) 18.42 39.61 (j)

121.47 (f) 92.70 (f) 89.3 (g) 3.43 (g) 60.82 (h) 19.58 (i) 19.18 41.25 (j)

coarse SO4

Fine

total H2SO4 organic

Filterable PM10

 of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or malfunction.

Condensable PM10

wo units with SCR+LNB+SOFA (0.07)

on”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating 

 are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. 
s 20.9% oxygen

W. is 17 lb/lb.mol

 = volume of 1 ft3 of gas at STP

increase max heat input by factor of 1.126

e split is irrelevant, and only total amount of SO4 matters for modeling. (Since all SO4 forms are assumed to be 

2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for PRB coal 

oth about 0.0067 = 0.67%, see below
lb/hr lb/hr lb mole/hr lb mole/hr mole ratio lb mole/hr lb mole/hr lb mole/hr

80.01 4.49 (k) 0.264 0.816 0.323 0.552 0.264 0.000 

83.31 4.68 (k) 0.275 0.849 0.323 0.575 0.275 0.000 

Ammonia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

[H2SO4]

[NH3] / 

[H2SO4] 

ratio

[H2SO4] 

after 

reaction

[AbS] or 

[NH4HSO4] 

after 

reaction

[AS] or 

[(NH4)2SO

4] after 

reaction

malfunction.

H2SO4 

before NH3 

interaction, 

after ESP

NH3 Slip [NH3]

H2SO4 HCl HF HCl + HF

lb mole/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtu lb/mmbtu lb/Mmbtu lb/hr

0.000 0.00 19.86 18.41 231.98 0.0019 0 0 0

0.000 0.00 20.68 19.17 276.086 0.0019 0 0 0

onia slip and Modeling SO4

H2SO4 + 

AbS + AS 

post-control

Total 

Effective 

SO4 for 

modeling

Total PM10 [NH3] after 

reaction

Net NH3 

after 

reaction & 

WFGD

For copying to Word version of tables

Highlight numbers portion of table here, copy; then goto Word, highlight numbers section of i

f5: SCR on #1,#3 w/incr capy; close #2

Filterable PM10

HCl+HF+

Pmfine

Max Heat 

Input SO2 NOx H2SO4 NH3 PM coarse

new PM 

fine MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

71.91 Unit 1 9,903 0.06 0.07 0.0019 0 0.010

Unit 2 0 0.00 0.00 0.0000 0 0.000

89.27 Unit 3 10,311 0.06 0.07 0.0019 0 0.012

Filterable PM10

Max Heat 

Input SO2 NOx H2SO4 NH3 PM coarse

MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Unit 1 9,903 549.21 693.20 18.80 0 97.84

Unit 2 0 0.00 0.00 0.00 0 0.00

Unit 3 10,311 648.76 721.79 19.58 0 121.47

1414.99

ight numbers section of its table, paste

Filterable PM10 Condensable PM10 (CPM)Filterable PM

PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.007 0.00028 0.0019 0.0040 0.026

0.000 0.00000 0.0000 0.0000 0.000

0.009 0.00033 0.0019 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM) lb/hr with pollutants in order expected by CALPU

PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/hr lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4

71.91 2.76 18.41 39.61 257.48 f5 NGS1 549.21 18.41

0.00 0.00 0.00 0.00 0.00 f5 NGS2 0.00 0.00

89.27 3.43 19.17 41.25 319.65 f5 NGS3 648.76 19.17

order expected by CALPUFF, rounded to 2 decimals

NOX HNO3 NO3 SOA PMF PMC EC

693.20 0 0 39.61 71.91 97.84 2.76

0.00 0 0 0.00 0.00 0.00 0.00

721.79 0 0 41.25 89.27 121.47 3.43
EPA revisions to values used in ANPRM

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

211,074 8,795 0.593 5.85 487.75

Navajo 2

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

56,993 2,375 0.593 1.59 132.78

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

219,778 9,157 0.593 6.91 576.17

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of 

(h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Res

value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 10

EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 19

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs 

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/0

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a he

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/1

malfunction.

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/1

f6: Reduce net capa

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions 
EPA Revisions for Final Rule

(1) Decrease total net capacity of Unit 2 by 561 MW. 189 MW is 0.252 of 750 MW. 

(2) decrease daily SO2 emissions by factor of 0.252

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 

(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Ea

PRB coal (strongly alkaline coal)

EPA revisions to Values used in ANPRM (3-7-11)

(1) set HCl and HF to zero
lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr

0.055 51% 25.33 2,110.74 0.240 0.0260 228.66 153.20 (f)

0.056 86% 6.84 569.93 0.240 0.0210 49.87 33.41 (f)

0.063 47% 26.37 2,197.78 0.240 0.0310 283.88 190.20 (f)

.5) based on AP-42, Table 1.1-6, September 1998.

stion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boye

er Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% durin

ater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.59

42, Table 1.1-5, September 1998. 

tnotes/emission inputs are explained separately

3 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

fur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

3 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year perio

3 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

Maximum Filterable

PM Emissions

total

Maximum Emissions Including Speciated PM10 Emissions 

Navajo Units 1, 2, and 3

f6: Reduce net capacity on all 3 units by 561 MW total, operate with LNB+SOFA

m SO2 Emissions (c) Maximum NOx Emissions (d)
ugh air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 
fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j)

18.95 (f) 14.46 (f) 13.9 (g) 0.54 (g) 10.14 (h) 0.64 (i) 0.63 9.50 (j)

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j)

bon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

 Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating 

s are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. 

organic

e of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

Filterable PM10 Condensable PM10

coarse

Fine

total H2SO4 SO4

LNB+SOFA
2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for 
H2SO4 HCl HF HCl + HF HCl+HF+

Pmfine

HCl+HF+

Pmfine EC

lb/hr lb/mmbtu lb/mmbtu lb/Mmbtu lb/hr new PM 

fine lb/mmbtu lb/mmbtu

190.76 0.00027 0 0 0.00 63.86 0.007 0.00028

43.55 0.00027 0 0 0.00 13.93 0.006 0.00023

229.30 0.00027 0 0 0.00 79.28 0.009 0.00033

Total PM10

For copying to Word versio

Highlight numbers portion of table h

f6: LNB+SOFA on #1,2,3; reduce 

coarse SO4 organic Max Heat 

Input

lb/mmbtu lb/mmbtu lb/mmbtu MMBtu/hr

0.010 0.00026 0.0040 Unit 1 8,795

0.008 0.00026 0.0040 Unit 2 2,375

0.012 0.00026 0.0040 Unit 3 9,157

Max Heat 

MMBtu/hr

Unit 1 8,795

Unit 2 2,375

Unit 3 9,157

ying to Word version of tables

umbers portion of table here, copy; then in Word, highlight numbers section of its table, paste

OFA on #1,2,3; reduce capy by 561 MW

Filterable PM10 Condensable PM10 (CPM)Filterable PM

SO2 NOx H2SO4 NH3 PM coarse PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.06 0.24 0.00027 0 0.010 0.007 0.00028 0.00026 0.0040 0.026

0.06 0.24 0.00027 0 0.008 0.006 0.00023 0.00026 0.0040 0.021

0.06 0.24 0.00027 0 0.012 0.009 0.00033 0.00026 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM)Filterable PM

SO2 NOx H2SO4 NH3 PM coarse PM fine PM fine inorganic organic Max Stack 

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

487.75 2110.74 2.37 0 86.89 63.86 2.45 2.32 35.18 228.66

132.78 569.93 0.64 0 18.95 13.93 0.54 0.63 9.50 49.87

576.17 2197.78 2.47 0 107.87 79.28 3.05 2.42 36.63 283.88

Filterable PM

Filterable PM lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

scen SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF

f6 NGS1 487.75 2.32 2110.74 0 0 35.18 63.86

f6 NGS2 132.78 0.63 569.93 0 0 9.50 13.93

f6 NGS3 576.17 2.42 2197.78 0 0 36.63 79.28

PMC EC

86.89 2.45

18.95 0.54

107.87 3.05
EPA revisions to values used in Proposed Rule

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SCR, hot side ESP, 

wet FGD

211,074 8,795 0.593 5.85 487.75

Navajo 2

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

56,993 2,375 0.593 1.59 132.78

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SCR, hot side ESP, 

wet FGD

219,778 9,157 0.593 6.91 576.17

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/1

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Res

value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 10

EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 19

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs 

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/0

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a he

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/1

malfunction.

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of 

(h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

f7: Reduce net capacity on Unit 2 by 5

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions 
EPA Revisions for Final Rule

(1) Decrease total net capacity on Unit 2 by 561 MW. (decrease max daily heat input by factor of 0.252 for unit2)

(2) install and operate SCR on the two units still at full capacity

(3) decrease daily SO2 emissions by factor of 0.252 on unit 2

(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Ea

PRB coal (strongly alkaline coal)

EPA revisions to Values used in ANPRM (3-7-11)

(1) set HCl and HF to zero

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 
lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr

0.055 86% 7.39 615.63 0.070 0.0260 228.66 153.20 (f)

0.056 86% 6.84 569.93 0.240 0.0210 49.87 33.41 (f)

0.063 85% 7.69 641.02 0.070 0.0310 283.88 190.20 (f)

3 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

Maximum Filterable

PM Emissions

.5) based on AP-42, Table 1.1-6, September 1998.

er Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% durin

ater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.59

42, Table 1.1-5, September 1998. 

tnotes/emission inputs are explained separately

3 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

fur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

3 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year perio

stion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boye

Maximum Emissions Inclu

pacity on Unit 2 by 561 MW operate with LNB+SOFA on Unit 2, install SCR+LNB+SOFA on 2 

m SO2 Emissions (c) Maximum NOx Emissions (d)

total
0.252 for unit2)

ugh air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 
fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 51.88 (h) 16.70 (i) 16.36 35.18 (j)

18.95 (f) 14.46 (f) 13.9 (g) 0.54 (g) 10.14 (h) 0.64 (i) 0.63 9.50 (j)

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 54.02 (h) 17.39 (i) 17.03 36.63 (j)

Filterable PM10 Condensable PM10

 Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating 

s are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. 

organic

e of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

bon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

SO4

aximum Emissions Including Speciated PM10 Emissions 

Navajo Units 1, 2, and 3

l SCR+LNB+SOFA on 2 units

coarse

Fine

total H2SO4
2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for 
lb/hr lb/hr lb mole/hr lb mole/hr mole ratio lb mole/hr lb mole/hr lb mole/hr

71.06 0.00 (k) 0.000 0.724 0.000 0.724 0.000 0.000 

2.73

73.99 0.00 (k) 0.000 0.754 0.000 0.754 0.000 0.000 

H2SO4 

before NH3 

interaction, 

after ESP

NH3 Slip [NH3] [H2SO4]

[NH3] / 

[H2SO4] 

ratio

[H2SO4] 

after 

reaction

[AbS] or 

[NH4HSO4] 

after 

reaction

[AS] or 

[(NH4)2SO

4] after 

reaction

H2SO4 HCl HF HCl + HF

lb mole/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtu lb/mmbtu lb/Mmbtu lb/hr

0.000 0.00 16.70 16.35 205.08 0.00190 0 0 0.00

0.63 43.55 0.00027 0 0 0.00

0.000 0.00 17.39 17.03 244.22 0.00190 0 0 0.00

Net NH3 

after 

reaction & 

WFGD

H2SO4 + 

AbS + AS 

post-control

Total 

Effective 

SO4 for 

modeling

Total PM10 [NH3] after 

reaction

HCl+HF+

Pmfine

HCl+HF+

Pmfine EC coarse SO4 organic

new PM 

fine lb/mmbtu lb/mmbtu lb/mmbtu lb/mmbtu lb/mmbtu

63.86 0.007 0.00028 0.010 0.00186 0.0040

13.93 0.006 0.00023 0.008 0.00026 0.0040

79.28 0.009 0.00033 0.012 0.00186 0.0040

For copying to Word version of tables

Highlight numbers portion of table here, copy; then in Word, highlight numbers section of its table, paste

f7: SCR on #1,#3; LNB+SOFA on #2; reduce capy by 561 MW

Filterable PM10

Max Heat 

Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil

MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 8,795 0.06 0.07 0.00190 0 0.010 0.007

Unit 2 2,375 0.06 0.24 0.00027 0 0.008 0.006

Unit 3 9,157 0.06 0.07 0.00190 0 0.012 0.009

Filterable PM10

Max Heat SO2 NOx H2SO4 NH3 PM coarse PM fine 

MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Unit 1 8,795 487.75 615.63 16.70 0 86.89 63.86

Unit 2 2,375 132.78 569.93 0.64 0 18.95 13.93

Unit 3 9,157 576.17 641.02 17.39 0 107.87 79.28

section of its table, paste

Condensable PM10 (CPM)Filterable PM

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.00028 0.00186 0.0040 0.026

0.00023 0.00026 0.0040 0.021

0.00033 0.00186 0.0040 0.031

Condensable PM10 (CPM)Filterable PM lb/hr with pollutants in order expected by CALPUFF, round

PM fine inorganic organic Max Stack 

lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX

2.45 16.36 35.18 228.66 f7 NGS1 487.75 16.36 615.63

0.54 0.63 9.50 49.87 f7 NGS2 132.78 0.63 569.93

3.05 17.03 36.63 283.88 f7 NGS3 576.17 17.03 641.02

ected by CALPUFF, rounded to 2 decimals

HNO3 NO3 SOA PMF PMC EC

0 0 35.18 63.86 86.89 2.45

0 0 9.50 13.93 18.95 0.54

0 0 36.63 79.28 107.87 3.05
EPA revisions to values used in Proposed Rule

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

158,306 6,596 0.593 4.39 365.81

Navajo 2

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

169,622 7,068 0.593 4.74 395.19

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

164,834 6,868 0.593 5.19 432.13

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs 

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/0

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a he

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/1

malfunction.

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/1

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of 

(h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Res

value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 10

EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 19

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

f8: Reduce net capacity on equally on 3 uni

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions 
EPA Revisions for Final Rule

(1) Decrease total net capacity on all 3 units equally by 561 MW. (i.e., apply factor of 0.75 to daily heat input for each unit - from 

(2) install and operate SCR on the two units still at full capacity

(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Ea

PRB coal (strongly alkaline coal)

EPA revisions to Values used in ANPRM (3-7-11)

(1) set HCl and HF to zero

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 
lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr

0.055 89% 5.54 461.72 0.070 0.0260 171.50 114.90 (f)

0.056 60% 20.35 1,696.22 0.240 0.0210 148.42 99.44 (f)

0.063 89% 5.77 480.76 0.070 0.0310 212.91 142.65 (f)

tnotes/emission inputs are explained separately

3 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

fur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

3 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year perio

3 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

.5) based on AP-42, Table 1.1-6, September 1998.

stion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boye

er Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% durin

ater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.59

42, Table 1.1-5, September 1998. 

total

Maximum Emissions Inclu

y on equally on 3 units by 561 MW operate with LNB+SOFA on Unit 2, install SCR+LNB+SOFA 

m SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable

PM Emissions
 heat input for each unit - from 1-(561/2250))

ugh air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 
fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

65.17 (f) 49.73 (f) 47.9 (g) 1.84 (g) 38.91 (h) 12.52 (i) 12.27 26.38 (j)

56.40 (f) 43.04 (f) 41.4 (g) 1.59 (g) 30.18 (h) 1.91 (i) 1.87 28.27 (j)

80.91 (f) 61.74 (f) 59.5 (g) 2.28 (g) 40.51 (h) 13.04 (i) 12.77 27.47 (j)

e of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

bon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

 Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating 

s are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. 

coarse

Fine

total H2SO4 SO4 organic

aximum Emissions Including Speciated PM10 Emissions 

Navajo Units 1, 2, and 3

 install SCR+LNB+SOFA on 2 units

Filterable PM10 Condensable PM10
2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for 
lb/hr lb/hr lb mole/hr lb mole/hr mole ratio lb mole/hr lb mole/hr lb mole/hr

53.29 0.00 (k) 0.000 0.543 0.000 0.543 0.000 0.000 

8.12

55.49 0.00 (k) 0.000 0.566 0.000 0.566 0.000 0.000 

[AS] or 

[(NH4)2SO

4] after 

reaction

[H2SO4]

[NH3] / 

[H2SO4] 

ratio

[H2SO4] 

after 

reaction

[AbS] or 

[NH4HSO4] 

after 

reaction

NH3 Slip [NH3]

H2SO4 

before NH3 

interaction, 

after ESP

H2SO4 HCl HF HCl + HF

lb mole/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtu lb/mmbtu lb/Mmbtu lb/hr

0.000 0.00 12.52 12.27 153.81 0.00190 0 0 0.00

1.87 129.62 0.00027 0 0 0.00

0.000 0.00 13.04 12.77 183.16 0.00190 0 0 0.00

Total 

Effective 

SO4 for 

modeling

Total PM10 [NH3] after 

reaction

Net NH3 

after 

reaction & 

WFGD

H2SO4 + 

AbS + AS 

post-control

HCl+HF+

Pmfine

HCl+HF+

Pmfine EC coarse SO4 organic

new PM 

fine lb/mmbtu lb/mmbtu lb/mmbtu lb/mmbtu lb/mmbtu

47.89 0.007 0.00028 0.010 0.00186 0.0040

41.45 0.006 0.00023 0.008 0.00026 0.0040

59.46 0.009 0.00033 0.012 0.00186 0.0040

For copying to Word version of tables

Highlight numbers portion of table here, copy; then in Word, highlight numbers section of its table, paste

f8: SCR on #1,#3; reduce capy by 561 MW on all three equally

Filterable PM10

Max Heat 

Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil

MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 6,596 0.06 0.07 0.00190 0 0.010 0.007

Unit 2 7,068 0.06 0.24 0.00027 0 0.008 0.006

Unit 3 6,868 0.06 0.07 0.00190 0 0.012 0.009

Filterable PM10

Max Heat SO2 NOx H2SO4 NH3 PM coarse PM fine 

MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Unit 1 6,596 365.81 461.72 12.52 0 65.17 47.89

Unit 2 7,068 395.19 1696.22 1.91 0 56.40 41.45

Unit 3 6,868 432.13 480.76 13.04 0 80.91 59.46

section of its table, paste

Condensable PM10 (CPM)Filterable PM

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.00028 0.00186 0.0040 0.026

0.00023 0.00026 0.0040 0.021

0.00033 0.00186 0.0040 0.031

Condensable PM10 (CPM)Filterable PM lb/hr with pollutants in order expected by CALPUFF, round

PM fine inorganic organic Max Stack 

lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX

1.84 12.27 26.38 171.50 f8 NGS1 365.81 12.27 461.72

1.59 1.87 28.27 148.42 f8 NGS2 395.19 1.87 1696.22

2.28 12.77 27.47 212.91 f8 NGS3 432.13 12.77 480.76

ected by CALPUFF, rounded to 2 decimals

HNO3 NO3 SOA PMF PMC EC

0 0 26.38 47.89 65.17 1.84

0 0 28.27 41.45 56.40 1.59

0 0 27.47 59.46 80.91 2.28
EPA revisions to values used in Proposed Rule

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

131,921 5,497 0.593 3.66 304.84

Navajo 2

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

226,163 9,423 0.593 6.32 526.92

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

137,361 5,723 0.593 4.32 360.10

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs 

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/0

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a he

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/1

malfunction.

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/1

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of 

(h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Res

value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 10

EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 19

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

f9: Reduce net capacity on equally on Units 1 and 3 b

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions 
EPA Revisions for Final Rule

(1) Decrease total net capacity on all 3 units equally by 561 MW. (i.e., apply factor of 0.75 to daily heat input for each unit - from 

(2) install and operate SCR on the two units still at full capacity

(3) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Ea

PRB coal (strongly alkaline coal)

EPA revisions to Values used in ANPRM (3-7-11)

(1) set HCl and HF to zero

(2) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 
lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr

0.055 91% 4.62 384.77 0.070 0.0260 142.91 95.75 (f)

0.056 46% 27.14 2,261.63 0.240 0.0210 197.89 132.59 (f)

0.063 90% 4.81 400.64 0.070 0.0310 177.42 118.87 (f)

tnotes/emission inputs are explained separately

3 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

fur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

3 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year perio

3 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

.5) based on AP-42, Table 1.1-6, September 1998.

stion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boye

er Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% durin

ater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.59

42, Table 1.1-5, September 1998. 

total

Maximum Emissions Inclu

ly on Units 1 and 3 by 561 MW total; operate with LNB+SOFA on Unit 2, install SCR+LNB+SO

m SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable

PM Emissions
 heat input for each unit - from 1-(561/2250))

ugh air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 
fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

54.31 (f) 41.45 (f) 39.9 (g) 1.53 (g) 32.42 (h) 10.44 (i) 10.22 21.99 (j)

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j)

67.42 (f) 51.45 (f) 49.5 (g) 1.90 (g) 33.76 (h) 10.87 (i) 10.64 22.89 (j)

e of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

bon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

 Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the heating 

s are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 0.9 x 0.47. 

coarse

Fine

total H2SO4 SO4 organic

aximum Emissions Including Speciated PM10 Emissions 

Navajo Units 1, 2, and 3

t 2, install SCR+LNB+SOFA on Units 1 and 3

Filterable PM10 Condensable PM10
2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for 
lb/hr lb/hr lb mole/hr lb mole/hr mole ratio lb mole/hr lb mole/hr lb mole/hr

44.41 0.00 (k) 0.000 0.453 0.000 0.453 0.000 0.000 

10.82

46.24 0.00 (k) 0.000 0.471 0.000 0.471 0.000 0.000 

[AS] or 

[(NH4)2SO

4] after 

reaction

[H2SO4]

[NH3] / 

[H2SO4] 

ratio

[H2SO4] 

after 

reaction

[AbS] or 

[NH4HSO4] 

after 

reaction

NH3 Slip [NH3]

H2SO4 

before NH3 

interaction, 

after ESP

H2SO4 HCl HF HCl + HF

lb mole/hr lb/hr lb/hr lb/hr lb/hr lb/mmbtu lb/mmbtu lb/Mmbtu lb/hr

0.000 0.00 10.44 10.22 128.18 0.00190 0 0 0.00

2.49 172.82 0.00027 0 0 0.00

0.000 0.00 10.87 10.64 152.63 0.00190 0 0 0.00

Total 

Effective 

SO4 for 

modeling

Total PM10 [NH3] after 

reaction

Net NH3 

after 

reaction & 

WFGD

H2SO4 + 

AbS + AS 

post-control

HCl+HF+

Pmfine

HCl+HF+

Pmfine EC coarse SO4 organic

new PM 

fine lb/mmbtu lb/mmbtu lb/mmbtu lb/mmbtu lb/mmbtu

39.91 0.007 0.00028 0.010 0.00186 0.0040

55.27 0.006 0.00023 0.008 0.00026 0.0040

49.55 0.009 0.00033 0.012 0.00186 0.0040

For copying to Word version of tables

Highlight numbers portion of table here, copy; then in Word, highlight numbers section of its table, paste

f9: SCR on #1,#3; reduce capy by 561 MW on #1, #3

Filterable PM10

Max Heat 

Input SO2 NOx H2SO4 NH3 PM coarse PM fine soil

MMBtu/hr lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

Unit 1 5,497 0.06 0.07 0.00190 0 0.010 0.007

Unit 2 9,423 0.06 0.24 0.00027 0 0.008 0.006

Unit 3 5,723 0.06 0.07 0.00190 0 0.012 0.009

Filterable PM10

Max Heat SO2 NOx H2SO4 NH3 PM coarse PM fine 

MMBtu/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Unit 1 5,497 304.84 384.77 10.44 0 54.31 39.91

Unit 2 9,423 526.92 2261.63 2.54 0 75.20 55.27

Unit 3 5,723 360.10 400.64 10.87 0 67.42 49.55

section of its table, paste

Condensable PM10 (CPM)Filterable PM

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.00028 0.00186 0.0040 0.026

0.00023 0.00026 0.0040 0.021

0.00033 0.00186 0.0040 0.031

Condensable PM10 (CPM)Filterable PM lb/hr with pollutants in order expected by CALPUFF, round

PM fine inorganic organic Max Stack 

lb/hr lb/hr lb/hr lb/hr scen SRCNAM SO2 SO4 NOX

1.53 10.22 21.99 142.91 f9 NGS1 304.84 10.22 384.77

2.12 2.49 37.69 197.89 f9 NGS2 526.92 2.49 2261.63

1.90 10.64 22.89 177.42 f9 NGS3 360.10 10.64 400.64

ected by CALPUFF, rounded to 2 decimals

HNO3 NO3 SOA PMF PMC EC

0 0 21.99 39.91 54.31 1.53

0 0 37.69 55.27 75.20 2.12

0 0 22.89 49.55 67.42 1.90
Parameter Unit 1 Unit 2 Unit 3 Parameter Unit 1 Unit 2 Unit 3

Height, ft 775 775 775 Height, m 236.2 236.2 236.2

Diameter, ft 24.5 24.5 24.50 Diameter, m 7.47 7.47 7.47

Flow, acfm 2,497,502 2,497,502 2,497,502 Flow, m3/s 1,178.7 1,178.7 1,178.7

Temperature, F 119 119 119 Temperature, K 321.5 321.5 321.5

Exit velocity, ft/min 5,298 5,298 5,298 Exit velocity, m/s 26.91 26.91 26.91

LC-X (km) -1267.800 -1267.790 -1267.750

LC-Y (km) -241.690 -241.784 -241.884

Navajo G.S. Stack Data (a)

09000064817e49bb Baseline stack data 7/28/2014
EPA revisions to values used in ANPRM

fine total fine soil EC

MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Navajo 1

750 MW, PC, 

biituminous coal, dry 

bottom, tangential 

fired, hot side ESP, 

wet FGD

211,074 8,795 0.593 5.85 487.75 0.055 #N/A 51.26 4,271.42 0.486 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j) 190.76

Navajo 2

750 MW, PC, 

biituminous coal, dry 

bottom, tangential 

fired, hot side ESP, 

wet FGD

226,163 9,423 0.593 6.32 526.92 0.056 #N/A 50.49 4,207.50 0.446 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j) 172.82

Navajo 3

750 MW, PC, 

biituminous coal, dry 

bottom, tangential 

fired, hot side ESP, 

wet FGD

219,778 9,157 0.593 6.91 576.17 0.063 #N/A 50.18 4,181.67 0.457 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j) 229.30

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs are explained separately

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the 

heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 

0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

Maximum Heat Input (a)

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998.

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

(h) Total condensible PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

total

(d) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

Total PM10

Unit

Maximum NOx Emissions (d)

(j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

Maximum Emissions Including Speciated PM10 Emissions 

Filterable PM10 Condensable PM10

Fine

Maximum Filterable

PM Emissions

Description

Navajo Units 1, 2, and 3

Baseline Conditions

Maximum SO2 Emissions (c)

total coarse H2SO4 SO4 organic

Maximum 

Sulfur 

Content (b)

Facility

09000064817e49bb n0 Base 7/28/2014
EPA revisions to values used in ANPRM

fine total fine soil EC

MMBtu/day MMBtu/hr % ton/day lb/hr lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry 

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

211,074 8,795 0.593 5.85 487.75 0.055 51% 25.33 2,110.74 0.240 0.0260 228.66 153.20 (f) 86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 2.32 35.18 (j) 190.76

Navajo 2

750 MW, PC, 

bituminous coal, dry 

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

226,163 9,423 0.593 6.32 526.92 0.056 46% 27.14 2,261.63 0.240 0.0210 197.89 132.59 (f) 75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 2.49 37.69 (j) 172.82

Navajo 3

750 MW, PC, 

bituminous coal, dry 

bottom, tangential 

fired, LNB, SOFA, hot 

side ESP, wet FGD

219,778 9,157 0.593 6.91 576.17 0.063 47% 26.37 2,197.78 0.240 0.0310 283.88 190.20 (f) 107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 2.42 36.63 (j) 229.30

Maximum Emissions Including Speciated PM10 Emissions 

Total PM10

Filterable PM10 Condensable PM10

Fine

Maximum Filterable

PM Emissions

Unit Description total

Maximum 

Sulfur 

Content (b)

Navajo Units 1, 2, and 3

Control Option 1: Low NOx Burners and Separated Overfire Air

Facility H2SO4 organic

Maximum SO2 Emissions (c)

total

Maximum Heat Input (a)

(j) Organic condensable PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 1998. 

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and the 

heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 98.06/32.07 x 0.63 x 

0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs are explained separately

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

coarse SO4

Maximum NOx Emissions (d)

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown or 

malfunction.

(d) Maximum daily/24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

(h) Total condensable PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1-6, September 1998.

09000064817e49bb n1 LNB 7/28/2014
Control Option 8: Low NOx Burners, Separated Overfire Air, and Selective Non-Catalytic Reduction 

MMBtu/day MMBtu/hr % ton/day lb/hr

Navajo 1

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SNCR, hot side ESP, 

wet FGD

211,074 8,795 0.593 5.85 487.75

Navajo 2

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SNCR, hot side ESP, 

wet FGD

226,163 9,423 0.593 6.32 526.92

Navajo 3

750 MW, PC, 

bituminous coal, dry

bottom, tangential 

fired, LNB, SOFA, 

SNCR, hot side ESP, 

wet FGD

219,778 9,157 0.593 6.91 576.17

Unit conversion for ammonia slip from ppmvd to lb/hr

NH3 5.00 ppmvd at 6% O2

Facility Unit Description

Maximum Heat Input (a)

Maximum 

Sulfur 

Content (b)

Maximum SO2 Emissions 

(f) For a dry bottom boiler with an ESP, 67% of filterable PM is PM10 and 29% is fine PM10 (PM2.5) based on AP-42, Table 1.1

** Below are the Original footnotes from AECOM - EPA revisions to the footnotes/emission inputs 

(a) Maximum daily 24 hour actual heat input based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 12/0

(b) Maximum fuel sulfur content is based on daily data for the 2001 to 2003 period. Maximum sulfur content is 0.593% with a he

(c) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 05/1

or malfunction.

(d) Maximum daily 24 hour actual emissions based on Part 75 monitoring data for the 2001 - 2003 period. Unit 1 based on 04/1

(e) Maximum of 6 stack test results for the 2001 to 2006 period.

(g) Elemental carbon is 3.7% of fine PM based on the best estimate for electric utility coal combustion in Table 6 of “Catalog of 

(h) Total condensible PM10 is the sum of H2SO4 and organic condensible PM10 emissions. 

(i) H2SO4 emissions are based on "Estimating Total Sulfuric Acid Emissions from Stationary Power Plants", Electric Power Res

the heating value is 10,496 Btu/lb. H2SO4 control efficiency is 37% for a hot side ESP, 10% for an air preheater, and 53% for w

98.06/32.07 x 0.63 x 0.9 x 0.47. EPRI (2008) Eqn 4-2b indicates that 95% of fuel sulfur is converted to SO2.

(j) Organic condensible PM10 is 0.20 x 0.02 lb/MMBtu = 0.004 lb/MMBtu with FGD based on AP-42, Table 1.1-5, September 19
0.00302 lb/MMBtu

unit 1 26.60 lb/hr

unit 2 28.50 lb/hr

unit 3 27.69 lb/hr

Penetration factors H2SO4 AbS and AS PM, general

p % ctrl p % ctrl p

hot-side ESP 0.63 37% 0.01 99% 0.01

Air Preheater 0.50 50% 0.75 25%

Wet FGD (scrubber) 0.47 53% 0.50 50%

EPRI H2SO4 doc EPRI NH3 doc

(2) updated Ammonia-Sulfuric acid reaction to accommodate full range of NH3/H2SO4 ratios, and accounted for molecular weig

(2) in sulfuric acid calculation, used EPRI 2010 Technical Update value of 0.5 for penetration through air preheater for low S Ea

PRB coal (strongly alkaline coal)

EPA revisions

(1) in sulfuric acid calculation, revised penetration factor for hot-side ESP from 1 (used in ANPRM) to 0.63. 
Non-Catalytic Reduction at 0.18 lb/MMBtu (Units 1, 2 & 3)

lb/MMBtu % reduction ton/day lb/hr lb/MMBtu lb/MMBtu(e) lb/hr lb/hr

0.055 63% 19.00 1,583.06 0.180 0.026 228.66 153.20 (f)

0.056 60% 20.35 1,696.22 0.180 0.021 197.89 132.59 (f)

0.063 61% 19.78 1,648.34 0.180 0.031 283.88 190.20 (f)

Method 19 (SO2 removal efficiency) formula, Eq. 19-1:

total

Maximum Emissions Including Speciated PM10 Emissions

Navajo Units 1, 2, and 3

m SO2 Emissions (c) Maximum NOx Emissions (d) Maximum Filterable

PM Emissions

.5) based on AP-42, Table 1.1-6, September 1998.

notes/emission inputs are explained separately

 period. Unit 1 based on 12/09/03, Unit 2 based on 11/13/02, and Unit 3 based on 01/31/02.

fur content is 0.593% with a heating value of 10,496 Btu/lb based on 01/08/03.

3 period. Unit 1 based on 05/19/03, Unit 2 based on 05/07/03, and Unit 3 based on 03/31/03. An average of 9 days/unit over the 3 year perio

3 period. Unit 1 based on 04/15/01, Unit 2 based on 03/12/01, and Unit 3 based on 03/26/01.

stion in Table 6 of “Catalog of Global Emissions Inventories and Emission Inventory Tools for Black Carbon”, William Battye and Kathy Boye

er Plants", Electric Power Research Institute, Technical Update, March, 2008 and Hardman et al., 1998. Oxidation of fuel S is 0.111% durin

n air preheater, and 53% for wet FGD. 100% of the flue gas is controlled by wet FGD. Therefore, H2SO4 emissions are determined by: 0.0

42, Table 1.1-5, September 1998. 
E = Cd*Fd*20.9/(20.9 - %O2d) Atmosphere is 20.9% oxygen

Cd = Pollutant concentration, dry basis Ammonia M.W. is 17 lb/lb.mol

Fd = volumes of combustion components per unit of heat content 385 ft3/lb-mol = volume of 1 ft3 of gas at STP

%O2d = Concentration of oxygen on a dry basis, percent.

Table 19-2 gives F factor for bituminous coal as Fd = 9780 sdcf/10^6 Btu

% ctrl

99%

d accounted for molecular weight of ammonium sulfate (AS) and bisulfate (AbS)

ugh air preheater for low S Eastern Bituminous coal (e.g. low alkalinity coal), changed slightly from EPRI 2008 value EPA used in ANPRM of 
fine total fine soil EC

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr

86.89 (f) 66.31 (f) 63.9 (g) 2.45 (g) 37.55 (h) 2.37 (i) 35.18 (j) 10.10

75.20 (f) 57.39 (f) 55.3 (g) 2.12 (g) 40.24 (h) 2.54 (i) 37.69 (j) 10.82

107.87 (f) 82.33 (f) 79.3 (g) 3.05 (g) 39.10 (h) 2.47 (i) 36.63 (j) 10.52

coarse

Fine

total H2SO4

Filterable PM10 Condensable PM10 H2SO4 

before NH3 

interaction, 

after ESP organic

 of 9 days/unit over the 3 year period were excluded because emissions reflected startup, shutdown 

on”, William Battye and Kathy Boyer, EPA Contract No. 68-D-98-046, January 2002.

Oxidation of fuel S is 0.111% during combustion (based on EPRI). Coal sulfur content is 0.593% and 

4 emissions are determined by: 0.00111 x 0.593%/100 x 1/10,496 x 1,000,000 x Heat Input x 
s 20.9% oxygen

W. is 17 lb/lb.mol

 = volume of 1 ft3 of gas at STP

2008 value EPA used in ANPRM of 0.49 and in lieu of the value of 0.36 cited in the EPRI 2010 for 
lb/hr lb mole/hr lb mole/hr mole ratio lb mole/hr lb mole/hr lb mole/hr lb mole/hr

26.60 (k) 1.562 0.103 15.167 0.000 0.000 0.103 1.356 

28.50 (k) 1.673 0.110 15.167 0.000 0.000 0.110 1.453 

27.69 (k) 1.626 0.107 15.167 0.000 0.000 0.107 1.412 

[NH3] [NH3] after 

reaction [H2SO4]

[NH3] / 

[H2SO4] 

ratio

[H2SO4] 

after 

reaction

[AbS] or 

[NH4HSO4] 

after 

reaction

NH3 Slip

Ammonia slip and reaction with sulfuric acid, for Net ammonia slip and Modeling SO4

[AS] or 

[(NH4)2SO

4] after 

reaction

For copying to Word version of tables

Highlight numbers portion of table here, copy; then in Word, hig

Control Option 8: SNCR Units 1 - 3

Max Heat 

Input SO2 NOx

lb/hr lb/hr lb/hr lb/hr MMBtu/hr lb/MMBtu lb/MMBtu

2.309 3.197 2.32 191.58 Unit 1 8,795 0.06 0.18

2.474 3.426 2.490 173.708 Unit 2 9,423 0.06 0.18

2.404 3.329 2.420 230.158 Unit 3 9,157 0.06 0.18

Max Heat 

Input SO2 NOx

MMBtu/hr lb/hr lb/hr

Unit 1 8,795 487.75 1583.06

Unit 2 9,423 526.92 1696.22

Unit 3 9,157 576.17 1648.34

4927.61

Total PM10

Net NH3 

after 

reaction & 

WFGD

H2SO4 + 

AbS + AS 

post-control

Total 

Effective 

SO4 for 

modeling

 Modeling SO4

ion of tables

 here, copy; then in Word, highlight numbers section of its table, paste

Filterable PM10 Condensable PM10 (CPM)Filterable PM

H2SO4 NH3 PM coarse PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu

0.0003 0 0.010 0.000 0.00028 0.0003 0.0040 0.026

0.0003 0 0.008 0.000 0.00023 0.0003 0.0040 0.021

0.0003 0 0.012 0.000 0.00033 0.0003 0.0040 0.031

Filterable PM10 Condensable PM10 (CPM)Filterable PM lb/hr with pollutants 

H2SO4 NH3 PM coarse PM fine 

soil

PM fine 

EC

inorganic 

(SO4)

organic 

(SOA)

Max Stack 

Test

lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr scen

2.37 0 86.89 0.03 2.45 2.32 35.18 228.66 n8

16.70 0 75.20 0.02 2.12 2.49 37.69 197.89 n8

16.70 0 107.87 0.03 3.05 2.42 36.63 283.88 n8

lb/hr with pollutants in order expected by CALPUFF, rounded to 2 decimals

SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC

NGS1 487.75 2.32 1583.06 0 0 35.18 0.03 86.89 2.45

NGS2 526.92 2.49 1696.22 0 0 37.69 0.02 75.20 2.12

NGS3 576.17 2.42 1648.34 0 0 36.63 0.03 107.87 3.05
NFRM CALPUFF Emissions, lb/hr

Scenario Name Code SRCNAM SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC

NGS1 487.75 16.35 483.71 0 0 35.18 63.86 86.89 2.45

NGS2 526.92 17.52 518.29 0 0 37.69 55.27 75.20 2.12

NGS3 576.17 17.03 503.66 0 0 36.63 79.28 107.87 3.05

NGS1 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45

NGS2 0 0 0 0 0 0 0 0 0

NGS3 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05

NGS1 487.75 16.35 615.63 0 0 35.18 63.86 86.89 2.45

NGS2 0 0 0 0 0 0 0 0 0

NGS3 576.17 17.03 641.02 0 0 36.63 79.28 107.87 3.05

NGS1 549.21 2.62 2376.69 0 0 39.61 71.91 97.84 2.76

NGS2 0 0 0 0 0 0 0 0 0

NGS3 648.76 2.73 2474.70 0 0 41.25 89.27 121.47 3.43

NGS1 549.21 18.41 693.20 0 0 39.61 71.91 97.84 2.76

NGS2 0 0 0 0 0 0 0 0 0

NGS3 648.76 19.17 721.79 0 0 41.25 89.27 121.47 3.43

NGS1 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45

NGS2 132.78 0.63 569.93 0 0 9.50 13.93 18.95 0.54

NGS3 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05

NGS1 487.75 16.36 615.63 0 0 35.18 63.86 86.89 2.45

NGS2 132.78 0.63 569.93 0 0 9.50 13.93 18.95 0.54

NGS3 576.17 17.03 641.02 0 0 36.63 79.28 107.87 3.05

NGS1 365.81 12.27 461.72 0 0 26.38 47.89 65.17 1.84

NGS2 395.19 1.87 1696.22 0 0 28.27 41.45 56.40 1.59

NGS3 432.13 12.77 480.76 0 0 27.47 59.46 80.91 2.28

NGS1 304.84 10.22 384.77 0 0 21.99 39.91 54.31 1.53

NGS2 526.92 2.49 2261.63 0 0 37.69 55.27 75.20 2.12

NGS3 360.10 10.64 400.64 0 0 22.89 49.55 67.42 1.90

NGS1 487.75 2.32 4271.42 0 0 35.18 63.86 86.89 2.45

NGS2 526.92 2.49 4207.50 0 0 37.69 55.27 75.20 2.12

NGS3 576.17 2.42 4181.67 0 0 36.63 79.28 107.87 3.05

NGS1 487.75 2.32 2110.74 0 0 35.18 63.86 86.89 2.45

NGS2 526.92 2.49 2261.63 0 0 37.69 55.27 75.20 2.12

NGS3 576.17 2.42 2197.78 0 0 36.63 79.28 107.87 3.05

NGS1 487.75 2.32 1583.06 0 0 35.18 0.03 86.89 2.45

NGS2 526.92 2.49 1696.22 0 0 37.69 0.02 75.20 2.12

NGS3 576.17 2.42 1648.34 0 0 36.63 0.03 107.87 3.05

Baseline n0

Control 1: LNB n1

Control 8: SNCR n8

TWG A3-2031a f7

TWG A3-2031b f8

TWG A3-2013c f9

TWG A2-2020 f4

TWG A2-2031 f5

TWG A3-2020 f6

SCR is BART f1

TWG A1-2020 f2

TWG A1-2031 f3
NFRM CALPUFF

Scenario Name Code

Baseline n0

Control 1: LNB n1

Control 8: SNCR n8

TWG A3-2031a f7

TWG A3-2031b f8

TWG A3-2013c f9

TWG A2-2020 f4

TWG A2-2031 f5

TWG A3-2020 f6

SCR is BART f1

TWG A1-2020 f2

TWG A1-2031 f3

Percent change from Baseline (n0) Emissions

SO2 SO4 NOX HNO3 NO3 SOA PMF PMC EC

-- 604.7% -88.7% -- -- -- -- -- --

-- 603.6% -87.7% -- -- -- -- -- --

-- 603.7% -88.0% -- -- -- -- -- --

-- -- -50.6% -- -- -- -- -- --

-100% -100% -100% -- -- -100% -100% -100% -100%

-- -- -47.4% -- -- -- -- -- --

-- 604.7% -85.6% -- -- -- -- -- --

-100% -100% -100% -- -- -100% -100% -100% -100%

-- 603.7% -84.7% -- -- -- -- -- --

12.6% 12.9% -44.4% -- -- 12.6% 12.6% 12.6% 12.7%

-100% -100% -100% -- -- -100% -100% -100% -100%

12.6% 12.8% -40.8% -- -- 12.6% 12.6% 12.6% 12.5%

12.6% 693.5% -83.8% -- -- 12.6% 12.6% 12.6% 12.7%

-100% -100% -100% -- -- -100% -100% -100% -100%

12.6% 692.1% -82.7% -- -- 12.6% 12.6% 12.6% 12.5%

-- -- -50.6% -- -- -- -- -- --

-74.8% -74.7% -86.5% -- -- -74.8% -74.8% -74.8% -74.5%

-- -- -47.4% -- -- -- -- -- --

-- 605.2% -85.6% -- -- -- -- -- --

-74.8% -74.7% -86.5% -- -- -74.8% -74.8% -74.8% -74.5%

-- 603.7% -84.7% -- -- -- -- -- --

-25.0% 428.9% -89.2% -- -- -25.0% -25.0% -25.0% -24.9%

-25.0% -24.9% -59.7% -- -- -25.0% -25.0% -25.0% -25.0%

-25.0% 427.7% -88.5% -- -- -25.0% -25.0% -25.0% -25.2%

-37.5% 340.5% -91.0% -- -- -37.5% -37.5% -37.5% -37.6%

-- -- -46.2% -- -- -- -- -- --

-37.5% 339.7% -90.4% -- -- -37.5% -37.5% -37.5% -37.7%

-- -- -- -- -- -- -- -- --

-- -- -- -- -- -- -- -- --

-- -- -- -- -- -- -- -- --

-- -- -50.6% -- -- -- -- -- --

-- -- -46.2% -- -- -- -- -- --

-- -- -47.4% -- -- -- -- -- --

-- -- -62.9% -- -- -- -99.95% -- --

-- -- -59.7% -- -- -- -99.96% -- --

-- -- -60.6% -- -- -- -99.96% -- --